jq# C l7~ ANL-92/5 Materials and Components Technology Division Materials and Components Technology Division Materials and Components Technology Division Detection and Location of Leaks in District Heating Steari Systems: Survey and Review of Current Technology and Practices by D. S. K upperman, A. C. Raptis, and R. L. Lanham Technoloav Division Technology Divisicn Materials and Components Technology Division Materials and Components Technology Division 0 Argonne National Laboratory, Argonne. Illinois 60439 operated by The University of Chicago for the United States Department of Energy under Contract W-31-109-Eng-38 4ecnrlbogy UiJvision
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and Review of Current Technology and Practices/67531/metadc... · 1 Introduction The cost of building and maintaining thermal distribution systems contributes substantially to the
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jq# C l7~ANL-92/5
Materials and ComponentsTechnology Division
Materials and ComponentsTechnology Division
Materials and ComponentsTechnology Division
Detection and Locationof Leaks in District Heating
Steari Systems: Survey
and Review of CurrentTechnology and Practices
by D. S. K upperman, A. C. Raptis,and R. L. Lanham
Technoloav Division
Technology DivisicnMaterials and Components
Technology DivisionMaterials and Components
Technology Division
0Argonne National Laboratory, Argonne. Illinois 60439operated by The University of Chicagofor the United States Department of Energy under Contract W-31-109-Eng-38
4ecnrlbogy UiJvision
Argonne National Laboratory, with facilities in the states of Illinois and Idaho, isowned by the United States government, and operated by The University oftChicagounder the provisions of a contract with the Department of Energy.
DISCLAIMER This report was prepared as an account of work sponsored by al) agency ofthe United States Government. Neither the United States Government nor
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favoring by the United States Government or any agency thereof. The views
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ANL--92/5
ANL-92/5 DE92 013740
Detection and Location of Leaks in District Heating Steam Systems:Survey and Review of Current Technology and Practices
D. S. Kupperman, A. C. Raptis,and R. N. Lanham
Materials and Components Technology Division
March 1992
Work supported by the MASTERU.S. DEPARTMENT OF ENERGY,
Assistant Secretary for Conservation and Renewable Energy,Utilities Systems Division
", j
TPL N c*: THI DOCUMENT IS UNLMITED
Contents
A re c t . . . . . . ............................................ ....................................................... 1
Ab s t r a c t .............................................................. 3
2 B ackground .......................................................................................................... 4
2.1 Existing Techniques for Leak Detection and Location............. 52.1.1 Acoustic Emission..................................................................... 52.1.2 Infrared Spectroscopy ............................................................ 62.1.3 Tracer Gas.................................................................................... 72.1.4 E lectrical...................................................................................... 82.1.5 Summary of Existing Techniques...................................... 8
2.2 In-Stream Acoustic Monitoring of Leaks........................................ 9
3 Review of Literature Related to Acoustic Leak Detection inDistrict Heating Systems .................................................................................. 10
4 Survey of District Heating Leak Detection andSP c ................................................................................................ 1 2
8 General Interest in ANL Technology............................................................ 27
9 Specific Interest in ANL Technology........................................................... 31
iv
Detection and Location of Leaks in District Heating Steam Systems:Survey and Review of Current Technology and Practices
by
D. S. Kupperman, A. C. Raptis, and R. N. Lanham
Executive Summary
This report presents the results of a survey undertaken to identify andcharacterize current practices for detecting and locating leaks in districtheating (DH) systems, in particular steam systems. Currently usedtechnology and practices are also reviewed. In addition, the survey was usedto gather information of potential importance in the application of acousticleak detection. Discussion is included of a few examples of attempts tolocate leaks in steam and hot water pipes by correlation of acoustic signalsgenerated by the leaks.
Several leak detection techniques are currently available. Theapplication and effectiveness of each technique depend on the design andinstallation method of the DH piping, location of the leak (in the jacket orthe carrier pipe), system operating parameters, and knowledge of systemlayout and components. The most common systems used today areclassified according to their principle of operation, i.e., acoustic emission,infrared spectroscopy, tracer gas, and electrical.
Acoustic leak detection is potentially the most effective method forlocating leaks. However, sensors placed directly on the pipe outer wall maynot be effective enough to locate steam leaks by acoustic techniques in longruns of DH piping. One way to circumvent the general problem of steamleak detection in buried pipe is to insert an acoustic transducer inside thepipe to directly detect steam-propagated sound waves. This concept is thefocus of a program at Argonne National Laboratory (ANL) cofunded byConsolidated Edison of New York and NRG Thermal (a subsidary of NorthernStates Power).
The conclusions from the survey are presented below.
2
1. The extent to which leak detection is considered important varies
significantly from utility to utility. At least three of the larger utilities spend$1 million or more each year locating and repairing leaks. One-half of therespondents do not consider leaks to be a problem and/or are satisfied withcurrent leak location methods.
2. The most common leak location method is to feel the pavement todetermine hot spots and/or to focus on specific trouble-spot componentsusing as-built drawings.
3. Almost one-quarter (23%) of the respondents have found anacoustic technology useful to some extent in leak location, while 18% havetried an acoustic technology without success. The effectiveness of variousacoustic or vibration-sensing devices appears to depend on several factors,including the device used, staff expertise and experience, soil type, and pipedepth. One-half of the respondents who indicated that they found anexisting acoustic technology useful also stated that they are interested in theANL technology because they feel that current methods are not as effectiveas the respondents would like.
4. Most utilities are reluctant to do hot taps, and this presents asignificant potential barrier to the use of the proposed ANL leak detectionand location technology. (In a hot tap, a valve is attached to the pipe and amicrophone is inserted through the valve. The microphone need notremain in the pipe because the valve permits removal of the microphoneand isolation of the insertion hole.) Concern about hot taps appears to bebased on prior experience with large (several-inch) hot taps. However, themicrophone under development at ANL will employ a much smaller tap andmay relieve much of the present concern.
3
Abstract
This report presents the results of a survey undertaken to identify andcharacterize current practices for detecting and locating leaks in districtheating systems, particular steam systems. Currently used technology andpractices are reviewed. In addition, the survey was used to gatherinformation that may be important for the application of acoustic leakdetection. A few examples of attempts to locate leaks in steam and hotwater pipes by correlation of acoustic signals generated by the leaks are alsodiscussed.
1 Introduction
The cost of building and maintaining thermal distribution systemscontributes substantially to the cost of energy delivered to end users. Toimprove the competitiveness of existing DH systems, the capital, operating,and maintenance costs must be reduced. Thermal-distribution pipingsystems installed underground in densely populated areas are subject to avariety of internal and external conditions that reduce their performance.In particular, pipe leaks are a major cause of energy loss and maintenancecost over the life of a DH system. To minimize these losses and costs, leaksmust be detected, located, and repaired promptly.
This report presents the results of a survey undertaken to identify andcharacterize current practices for detecting and locating leaks in districtheating systems, in particular steam systems. The survey was used to gatherinformation on (a) characteristics of the distribution system that may beimportant for acoustic leak detection, (b) currently used technology andpractices, and (c) possible interest in acoustic leak detection technologysuch as that under development at Argonne National Laboratory (ANL). Inaddition, a review of leak detection technology and available literature onacoustic leak detection is presented. A few examples of attempts to locateleaks in steam and hot water pipes by correlation of acoustic signalsgenerated by the leaks are discussed.
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2 Background
Leak detection and location techniques are currently available forseveral configurations of heat distribution systems carrying water. 1 Theperformance of these techniques has not been well documented by theindustry. Most of the existing data are in the possession of individual systemoperators and have not been collected and disseminated to the industry. Inthis report, the results of a survey of utilities is presented, eliminating thisprevious gap in information. Until now, the only readily available data onleak detection techniques and their application and performance are thosedocumented by an evaluation study conducted by the ConstructionEngineering Research Laboratory (CERL) of the U.S. Army Corps ofEngineers.2 The conclusions of the CERL study were that every availableleak-detection technique is limited in application to a specific conduitconfiguration and installation technique. With regard to acoustic leakdetection in particular, several researchers have investigated the applicationof acoustic leak detection to other systems, including nuclear reactors, withsome success.3 7
The major elements of an underground thermal distribution systemare distribution piping, thermal insulation, pipe supports, anchors,expansion/contraction devices, conduit/envelope structures, protectiveouter coverings, joint sealants, external drains, and manholes. Among thefactors that influence the design, materials selection, and installationmethods for thermal distribution systems are initial cost, service life,maintenance costs, thermal and economic efficiency, and safety. In thepast, performance improvements in thermal distribution systems have beenminor.
Underground piping systems are installed and operated in very harshenvironments and their long-term reliability is highly dependent oncorrosion protection, installation technique, site hydrology, and propermaintenance. After a few years of operation, most underground pipingsystems are likely to incur leaks in the carrier pipe. If not detected andrepaired promptly, these leaks can cause major damage to a whole section ofa piping system and neighboring utilities, as well as substantial energylosses. Most of the historical data on the causes of piping leaks in theUnited States have been derived from steam distribution facilities of thefederal government. These data indicate that leaks in underground pipingsystems are often caused by corrosion, mechanical rupture due to soil
5
subsidence and pipe expansion, or construction deficiencies. In a studyconducted by a Swedish national laboratory on the failure of Swedish DHhot-water distribution pipes from 1968 to 1982, several key causes of pipeleaks were identified. 1
Although steam leaks in underground pipes of DH systems may nothave the safety significance of a leak in a nuclear reactor, they can behazardous to the public and costly in terms of energy loss. In St. Paul,Minnesota, for example, one energy system lost 50% of its steam outputthrough leakage before the system was repaired. The U.S. Department ofDefense maintains about 6000 miles of heat distribution lines, mainlyunderground, and energy loss has become a concern. 2 A reliable leakdetection and location system for underground piping could reduce thecosts of operating a DH system and minimize the general liability of thecompany providing the service. However, the task of finding leaks iscomplex because of the configuration of the distribution systems. Insulatedheat-carrying pipe, for example, can be supported inside a protective buriedonduit with an air space between the pipe insulation and the conduit's
inner wall. Supply and return lines can be in common or separate conduits.Alternatively, a concrete trench with removable covers can contain insulatedsupply and return lines.
2.1 Eristing Techniques for Leak Detection and Location
Various leak detection techniques are currently available. Theapplication and effectiveness of each technique depend on the design andinstallation method of the DH piping, location of the leak (in the jacket orthe carrier pipe), system operating parameters, and knowledge of systemlayout and components. The most common systems today are classifiedaccording to principle of operation as follows: acoustic emission, infraredspectroscopy, tracer gas, and electrical.
2.1.1 Acoustic Emission
When a leak occurs in a pipe carrying pressurized hot water or steam,the turbulent flow of the fluid passing through the crack or hole generatessound waves. These waves are omnidirectional and their intensity decreasesinversely with distance from the leak. Commercially available acoustic leakdetection and location systems incorporate acoustic sensors to detect andmeasure the intensity of the noise signal generated by a leak. Acoustic
6
signals can be detected by placing a sensing microphone in direct contact
with a carrier pipe at an accessible point. This method is more effective forwater-filled pipe because the sound in the water is coupled to the pipe walldue to the relatively small difference in acoustic impedances. For asteam-filled pipe, the acoustic impedance mismatch is much greater andthe sound propagating in the steam is not transferred readily to the pipewall; thus, sensors that detect leak noise by being placed on the pipe wallwould be less efficient than a sensor that could be inserted into the pipe.
Another approach to measuring the intensity of the acoustic leaksignal is bar-holing, in which a metal rod is driven into the ground toestablish metal-to-metal contact with the carrier pipe. The metal rod actsas a waveguide and the acoustic signal is measured at the upper end of therod. To locate the leak, multiple acoustic wave measurements are taken.The location is then found by comparing the measured intensities of theleak signal at various locations and identifying the point where it is highest.Another method is to move a microphone, in contact with the ground, alonga path following the pipe and use the maximum-amplitude noise signal tolocate a leak. The success of this method depends on the skill of theoperator and the configuration of the underground piping.
A more sophisticated and potentially cost-effective acoustic leakdetection/location technique requires only two measurements of theleak-noise signal and uses an advanced computerized system to analyze thesignals and locate the leak via a cros: :orrelation function. This function is amathematical concept that can be b epresented by a graph that plotsamplitude over time. In the absence of a leak, the graph is generally a seriesof small bumps caused by background noise. The appearance of a large peakindicates a leak. Time (how long it takes the signal to travel from the sourceto one of the two sensors) is easily converted to distance. By comparing thetime delays in signals received by the two sensors, we can accuratelypinpoint the leak.
2.1.2 Infrared Spectroscopy
A leaking steam pipe could increase the temperature of the groundand surface area above the leak. If the ambient temperature, depth of theleaking pipe, and variations in ground-surface temperature are withincertain limits, leaks can be detected by infrared spectroscopy. Atemperature profile of the surface above the pipeline, taken with a camera
7
mounted on a motor vehicle or helicopter, is compared to a referencetemperature profile taken when there were no leaks in the pipeline. Also,temperature-reading devices can be used to identify variations in groundtemperature and hot spots on the ground surface along the pipeline route.Hot spots identified by infrared spectroscopy are likely to be the locations ofpipe leaks.
Infrared spectroscopy is most effective when a leak occurs in both thecarrier pipe and its jacket at the same location. Soil condition, pipe systemdesign, installation technique, and leak type are critical factors in theapplication and effectiveness of this method. With certain ground soilconditions and installation techniques, leaking hot water may spread intothe surrounding soil and blur the leak source or it may be absorbed by thesoil and limit the effectiveness of the method. Accuracy is also limited whena leak occurs only in the carrier pipe or the jacket, and when there aremultiple leaks in the pipe system. In general, this method is not applicablein many commonly occurring leak situations and it is expensive.
2.1.3 Tracer Gas
The tracer gas method can be used to detect and locate leaks inunderground heat distribution systems that employ a double wall with anannular space between the carrier and the casing pipes. Heat distributionbased on this pipe design is found mostly in federal governmentinstallations. Leaks can be detected and located in both the carrier andcasing pipes. Gas is injected into the pipe system and its concentration ismeasured at the surface or in shallow bar-holes made at intervals about equalto the average depth of the conduit along the entire length of the pipesystem. The hole with the highest gas concentration will usually indicatethe location of the leak. Sulfur hexafluoride (SF6) is the most frequentlyused tracer gas because it does not occur naturally. Although this techniqueis feasible for detecting leaks in double-walled piping systems, it is notwidely used. A major disadvantage is the need to shut down the heatdistribution system when the carrier pipe is tested. Calculations todetermine diffusion time and leak location are often difficult. In testing forcasing leaks, a scan of the surface to detect the tracer gas and locate theleak is not always reliable because, depending on soil conditions, the leakinggas may either travel vertically or follow the path of least resistance.
8
2.1.4 Electrical
Most of the recently built DH hot water piping systems in the UnitedStates and Europe have factory-made insulated pipes that incorporateelectrical devices for detecting and locating leaks. To detect leaks in thecarrier pipe and casing, an exposed wire is installed in the pipe insulation;the electrical resistance between this electrical conductor and the metalcarrier pipe can then be measured and monitored. Leaks can be detected bycomparing the measured resistance with a minimum reference value.Another electrical method for locating leaks is based on time-domainreflectometry. When the outer braid of a coaxial cable, installed in the pipeinsulation, is infiltrated by a leaking fluid (groundwater from a leak in thecasing or hot water from a carrier pipe leak), it undergoes a change incharacteristic impedance at the leak. This change converts outgoingelectrical signals from the plant into reflected pulses or standing waves. Tolocate the leak, the signals are detected and analyzed at the plant withsignal-processing equipment.
The currently available electrical techniques for detecting and locatingleaks are used with preinsuiated pipe systems. These techniques have onlybeen used in the last 10-15 years in hot-water piping systems, and existingheat distribution installations cannot be retrofitted cost-effectively. Thelong-term reliability of electrical techniques has not been proved.Corrosion, the most common problem with underground piping systems, islikely to limit the life of the signal wires and reduce the long-termeffectiveness of this system.
2.1.5 Summary of Existing Techniques
All of the commonly used leak detection techniques have limitations.The infrared method is limited by high cost and "blurring" of the hot spot asheated water spreads into the surroundings or is directed away from thesource of the leak. Accuracy of the tracer gas method is limited by variationsin gas diffusion rates and preferential migration. Another disadvantage ofthe tracer gas method is that the DH system must be shut down when thepipes are tested. Electrical methods pose reliability problems and cannot beused in older systems. The acoL'stic method, though somewhat of an "art" inpractice, currently has the greatest potential for detecting leaks inunderground pipes.2
9
2.2 In-Stream Acoustic Monitoring of Leaks
Transducers or transducer/waveguide systems placed directly on thepipe outer wall may not be effective enough to locate leaks acoustically inlong runs of DH piping. Two factors contribute to the problem with
steam-filled pipes. The first is that acoustic impedance mismatch betweenthe pipe wall and the steam is so great that the amount of sound energycoupled into the pipe froi the steam is limited. (Sound traveling inside awater-filled pipe is efficiently coupled to the pipe wall and can be detectedby externally mounted transducers.) The effectiveness of cross-correlationanalysis for leak location in steam-filled pipes is further reduced by thenumerous modes of acoustic wave propagation present in the pipe wall.These modes are not normally present in water-filled pipes because of thedamping effect of the water.
One way to circumvent the general problem of steam leak detection inburied pipe is to insert an acoustic transducer inside the pipe for directdetection of steam-propagated sound waves. We briefly evaluated acapacitance-microphone-type transducer (Knowles Electronics, Inc., ModelBT-1834) that can be inserted into a pipe through a small hole. Thetransducer was inserted into the ANL test pipe through a hole used forartificial leaks. An Endevco 2224C accelerometer was placed on the outerwall of the pipe at the same location. The pipe was filled with gas at~6 psi pressure. The transducer showed superior signal-to-noise ratios overmost of the examined frequency range.' For example, near 4 kHz, thesignal-to-noise ratio for the capacitance microphone transducer is about 10dB higher than for the accelerometer. This advantage is reduced by a fewdecibels at higher frequencies (e.g., 10-12 kHz). Cross-correlation analysisof signals from a gas leak also suggests that these small transducers can besignificantly more effective than transducers mounted on the outside of thepipe. A well-defined correlation peak for a leak could not be obtained withexternally mounted accelerometers, whereas it could be with in-streamtransducers.
A potential problem with this concept is that, for continuousmonitoring, the transducer must be protected from the erosive andcorrosive effects of the fluid stream, as well as from the elevatedtemperatures. Furthermore, the sensor must be inserted so that the fluiddoes not create high levels of acoustic noise as it flows past the sensor.These problems can be overcome, and the advantage of not having to analyze
10
propagation modes in the pipe wall makes the pursuit of an intrusive sensorparticularly attractive for correlation analysis. A goal of the current programat ANL is the development of an in-stream acoustic sensor for steam leaklocation.
3 Review of Literature Related to Acoustic Leak Detection inDistrict Heating Systems
Several papers on the detection and location of leaks are brieflyreviewed below. In general, attempts to locate leaks acoustically haveconcentrated primarily on water filled pipes. No papers dedicated todetection and location of stear leaks have been found. In general, locationof leaks in water-filled pipes have been successful. Other references arepresented at the end of this report.
Ref. 8 "Acoustic leak location in district heating pipes."Fuchs, H.V., Frommhold, W., Poggemann, R., and Zenker, P.(Correlation analysis)Source: HLH, Heizung, Luftung, Klimatechnik, Haustechnik, v. 42:1;Fraunhofer-Institut fur Bauphysik, Stuttgart, and EnergieversorgungOberhausen AG (West Germany),Language: German
Leaks were found using LOKAL ('leak location through correlation. analysis"). Only water leaks were detected. Leaks were detectedwith frequencies less than 1 kHz and sensors placed on the pipeouter walL Location was by cross-correlation analysis. Leak ratescJ 0.05 to 3.5 m3/hr. were detected at distances up to 260 m.
Ref. 9 "Computer-aided measuring system for automatic monitoring of pipenetworks and leak detection." Schwarze, H.(Noise-correlation technique)Source: Technisches Messen, v. 55, no. 7-8, 1988, pp. 279-285;Fachhochschule Bielfeld, Bielfeld, West Germany.Language: German
Location of pipe leaks is determined by employing an LSI chipTDC1028 and three radio links to calculate the cross-correlationfunction. This work involves detection of water leaks only. The
11
frequencies of interest are 20 Hz to 10 kHz. Microphones areattached to hydrants. Electronic filters provide flexibility in selectionof frequencies (100 Hz to 5 kHz).
Ref. 10 "Leakage monitoring in synthetic jacket pipes for district heatingsupply." Micheel, H. J. (Impulse echo measurement)Source: Fernwarme International, v. 16, no. 6, Nov.-Dec. 1987, pp.380-385;Salzgitter Elektronik GmbH, Kiel, West Germany.Language: German
With a network of moisture indicators and wire leads, the location ofleaks is determined by insulation resistance measurement and impulseecho measurement.
Ref. 11 "Environmental monitoring technologies". Chang, D. B., Pierce, B.M., and Shih, I. Source: SAE Technical Paper Series 910190,International Congress and Exposition, Detroit, Michigan, Feb. 25-March 1, 1991Language: English
This paper discusses a fiber-optic liquid level sensor that may providean accurate measurement of leakage from underground storage tanks.Leaks are detected by measuring the change in light intensitytransmitted along a special fiber-optic cable. When the cable is incontact with the liquid (as it could be if it were buried and in contactwith a leaking fluid), the transmitted light is attenuated.
Ref. 12 "Leak location in district heating networks using acousticalcorrelation techniques." Turtiainen, H.(Acoustic correlation techniques)Source: Valtion Teknillinen Tutkimuskeskus, Espoo, Finland.Language: Finnish
The theoretical and applied sides of leak location through acousticcorrelation are based on experience with 17 real leaks.
Ref. 13 "In situ control of district heating networks." Gransell, H. andLjungquist, John.(Damage analysis and on-site measurements)
12
Source: Annual Conference of the Int'l District Heating Assn., v. 76;Studsvik Energiteknik AB,Language: English
Reports on damage analysis and on-site measurements, and describesmethods for leak detection.
Ref. 14 "Active acoustic detection of leaks in underground natural gas
distribution lines." Jette, A. N., Morris, M. S.; Murphy, J. C.; andParker, J. G.
sensor)Source: Materials Evaluation, v. 35, no. 10, Oct. 1977, pp. 90-96, 99;Johns Hopkins University, Baltimore, Maryland, USA.Language: English
Describes research. program aimed at understanding the acousticdetection of leaks in pipes.
Ref. 15 "Pipeline leak location using radiotracer technique." Eapen, A.C.,Ajmera, R.L., and Agashe, S.M.(Radiotracer technique)Source: Bhabha Atomic Research Centre, Bombay, India - Isotope Div.Language: English
Compares new radiotracer technique to other leak detection
techniques.
i
4 Survey of District Heating Leak Detection and Location Practices
This survey was undertaken as part of a joint program between theU.S. Department of Energy and utilities that operate district heating andcooling systems. The objective of the joint program is the development ofan in-stream acoustic sensor to locate steam leaks. The survey itself wasaimed at identifying and characterizing current practices for detecting andlocating leaks in district heating systems, specifically steam systems. This
13
information reflects the conditions, needs, and requirements of the DHindustry in developing acoustic leak detection technology
4.1 Survey Method
The survey was conducted through telephone contacts with utilitymembers of the International District Heating and Cooling Association(IDHA). Introductory remarks used in the survey, and the form used torecord the information obtained, are included in Appendix A.
The survey was designed to gather information in three major areas:(a) characteristics of the distribution system that may be relevant to designand implementation of the acoustic leak detection technology,(b) technologies and practices currently used by the utility to detect andlocate leaks, and (c) interest in utilizing the acoustic leak detectiontechnology developed by ANL.
Results of the survey are summarized below, and detailed notes areprovided in Appendix B.
4.2 Results
There are 59 companies listed as "utility" members of the IDHA. Ofthese, 3 are European, 4 are Japanese, 5 are planning systems that are notoperational yet, and. 3 are holding companies that own a number ofoperating district heating and cooling systems. All 44 of the operationalNorth American district heating and/or cooling system companies weresurveyed. Table 1 shows the names and telephone numbers of thecompanies and individuals contacted. In addition, investigations ofEuropean leak detection practices were made and summarized.
In Table 2, basic system data arc summarized. Of the 44 companiescontacted, 30 provide steam only, 9 provide steam plus chilled water and/orhot water, 2 provide hot water only, and 2 provide hot water and chilledwater.
Some of these systems have had pipe in the ground for many years. Ofthe 31 systems for which age data were given, 17 were at least 60 years old.
14
Table 1. Utilities Surveyed
Name of system Contact person Phone
Alabama Power CompanyBaltimore ThermalBoston ThermalCentral Heat Distribution (Vancouver)Cleveland ThermalCogeneration Management CompanyConcord SteamConsolidated EdisonDayton Power and LightDetroit EdisonDistrict Energy St. PaulEnergy Networks Inc.Energy Systems Co. - OmahaEugene Water and Electric BoardFairbanks Municipal UtilitiesGeorgia Power Co.Harrisburg Steam WorksIndianapolis Power and LightJamestown Board of Public UtilitiesKent County Public WorksLansing Board of Power and LightMid-America Energy ResourcesMinneapolis Energy CenterNashville ThermalNRG ThermalPacific Energy/Central Plants Inc.Pacific Gas and ElectricPACT, Ltd.Philadelphia ThermalPittsburgh ThermalPublic Service Co. of ColoradoRochester District Heating CooperativeSt. Louis ThermalSeattle SteamToronto District Heating Corp.Trenton District EnergyTrigen - TulsaTrigen - London, OntarioTrigen - Kansas CityTrigen - Nassau CountyUnited IlluminatingWillmar Public UtilitiesWisconsin ElectricYoungstown Thermal
Max. age Annual Miles (S = steam;of pipe sales of HW = hot water
Name of system (yr) (106 Btu)a pipe CW = cooling)
Alabama Power CompanyBaltimore ThermalBoston ThermalCentral Heat Distribution (Vancouver)Cleveland ThermalCogeneration Management CompanyConcord SteamConsolidated EdisonDayton Power and LightDetroit EdisonDistrict Energy St. PaulEnergy Networks Inc.Energy Systems Co. - OmahaEugene Water and Electric BoardFairbanks Municipal UtilitiesGeorgia Power Co.84Harrisburg Steam WorksIndianapuiis Power and LightJamestown Board of Public UtilitiesKent County Public WorksLansing Board of Power and LightMid-America Energy ResourcesMinneapolis Energy CenterNashville ThermalNRG ThermalPacific Energy/Central Plants Inc.Pacific Gas and ElectricPACT, Ltd.Philadelphia ThermalPittsburgh ThermalPublic Service Co. o% ColoradoRochester District Heating CooperativeSt. Louis ThermalSeattle SteamToronto District Heating Corp.Trenton District EnergyTrigen - TulsaTrigen - London, OntarioTrigen - Kansas CityTrigen - Nassau CountyUnited IlluminatingWillmar Public UtilitiesWisconsin ElectricYoungstown Thermal
70
6022
1560
89858
2480
84
77083
1
178
8070
90110
100308
21
852039
8690
Total
548,5221,b46,400 #
998,4731,399,648 #
300,00037,298,000
3,957,353824,557
1,003,932
467,881 #135,360 #107,300357,700
5,681,900
695,5681,882,858
1,714,208398,503
722,646
4,498,800598,882
1,038,000 #
999,559986,280
2,586,000447,000
120,000
55,6542,160,274
496,320
74,127,578
6 S15 S22 S5 S19 S1.5 S8 S
100 S15 S41 S20 MW17 S, HW, CW
S CW9 S
S, HW28 S7 S
S6 S
1.5 S12 S
Cw4 S, HW, CW
S, CW5.5 S
S, HW, CW11 S7 S
33 S1 S,CW11 S9 S
22 S18.5 S
12 SHW
2 S,CW4 S9 S9 HW, CW<1 HW, CW4 HW, S
28 S6 S
529
aFor 1989 except where marked with # (1988 data).
16
Two measures of system size are shown: annual energy sales and milesof supply piping. Although these data were not available for all utilities, thetotal energy sales for the utilities with such data was more than 74 x 1012Btu, and the total length of supply pipe was 530 miles. This information willbe useful in weighting the Importance of the responses. For example, theneeds of Consolidated Edison, with more than 50% of the total sales and25% of the supply piping, are extremely significant.
Table 3 summarizes the types of piping installations and expansiondevices used. Box conduit, solid pour, and prefabricated pipe conduit typesare it istrated in Fig. 1. While 41% of the respondents use prefabricatedconduit (pipe-within-pipe), this is often only their newer pipe. A majorexception is Consolidated Edison, whose standard design is a pipe-within-pipe with an annular space between the two.
The next most common installation is box conduit (36%), followed bydirect bury (32%), solid pour (25%), and tunnels (14%). Although nodefinite figures are available, box conduit probably represents the greatestnumber of pipe miles for utilities other than Consolidated Edison.
Slip joints and bellows are by far the most common expansion devices,and many utilities use both types. Slip joints are used by 57% of therespondents, and bellows by 55%, while only 9% use ball joints and 23% useexpansion loops.
Typical or average intervals between expansion devices and betweenmanholes are indicated in Table 4. The interval between expansion devicesis relevant due to the acoustic attenuation caused by such devices if sensorsare placed on the pipe surface. Interval between manholes is important if itis possible that the hot tap required for the ANL acoustic detection devicecan be done at manholes to minimize costs.
Of the 35 utilities providing steam pressure data, 16 provide highpressure and low pressure steam service (low pressure is defined here as 50psi or less), 14 provide only high-pressure service, 2 provide only low-pressure service, and 1 distributes 800-psi superheated steam.
Of the 32 systems providing high-pressure service, 15 operated at150 psi or less. Only 7 systems operated at pressures over 200 psi.
17
Table 3. Summary of Pipe Installations and Expansion Devices
Types of pipe Types ofinstallationsa expansion devicesb
Name of system BC SP T PC DB S Bel B EL
Alabama Power CompanyBaltimore ThermalBoston ThermalCentral Heat Distribution (Vancouver)Cleveland ThermalCogeneration Management CompanyConcord SteamConsolidated EdisonDayton Power and LightD'troit EdisonDistrict Energy St. PaulEnergy Networks Inc.Energy Systems Co. - OmahaEugene Water and Electric BoardFairbanks Municipal UtilitiesGeorgia Power Co.Harrisburg Steam WorksIndianapolis Power and LightJamestown Board of Public UtilitiesKent County Public WorksLansing Board of Power and LightMid-America Energy ResourcesMinneapolis Energy CenterNashville ThermalNRG ThermalPacific Energy/Central Plants Inc.Pacific Gas and ElectricPACT, Ltd.Philadelphia ThermalPittsburgh ThermalPublic Service Co. of ColoradoRochester District Heating CooperativeSt. Louis ThermalSeattle SteamToronto District Heating Corp.Trenton District EnergyTrigen - TulsaTrigen - London, OntarioTrigen - Kansas CityTrigen - Nassau CountyUnited IlluminatingWillmar Public UtilitiesWisconsin ElectricYoungstown The-rmal
0 " " "
0
" 0
0 0
"
"
" S 0
" " 0
0
0
" "
" "
"
"
"
S
"
"
"
0
"
0
"
"
" "
"
" " "
" "
" "
S
0
"
S
0
0
"
"
"
"
"
"
"
A
"
0
0
" "
" "
" "
"
"
" "
"
" "
0 00
S"
0
0
0
0
"
"
0
"
0
"
"
"
"
"
"
"
"
0
S "
"
S 0 0
" " 0 0
0
""
Totals% of respondents
aPipe Installations: BC = Box conduit; SP =or other pipe-within-pipe; DB = Direct Bury
Solid pour; T = Tunnel; PC = Prefabricated conduit
bExpansion Devices: S = Slip; Bel = Bellows; B = Ball; EL = Expansion loop.
BetwneeolesLwesNamefsystem erliuits manholes HP IP Yes No
Alabama Power CompanyBaltimore ThermalBoston ThermalCentral Heat Distribution (Vancouver)Cleveland ThermalCogeneration Management CompanyConcord SteamConsolidated EdisonDayton Power and LightDetroit EdisonDistrict Energy St. PaulEnergy Networks Inc.Energy Systems Co. - OmahaEugene Water and Electric BoardFairbanks Municipal UtilitiesGeorgia Power Co.Harrisburg Steam WorksIndianapolis Power and LightJamestown Board of Public UtilitiesKent County Public WorksLansing Board of Power and LightMid-America Energy ResourcesMinneapolis Energy CenterNashville ThermalNRG ThermalPacific Energy/Central Plants Inc.Pacific Gas and ElectricPACT, Ltd.Philadelphia ThermalPittsburgh ThermalPublic Service Co. of ColoradoRochester District Heating CooperativeSt. Louis ThermalSeattle SteamToronto District Heating Corp.Trenton District EnergyTrigen - TulsaTrigen - London, OntarioTrigen - Kansas CityTrigen - Nassau CountyUnited IlluminatingWillmar Public UtilitiesWisconsin ElectricYoungstown Thermal
Solid pour conduit Metal casing, prefabricated conduit
Fig. 1. Basic Piping Designs (from "District Heating Handbook, FourthEdition," International District Heating and Cooling Association, 1983)
MET AL
CASING
ONDE NSATE
RETURN
INSUL ATION
1
. , C
I
"co
" /
/*
20
"External sources" was cited as the most common leak problem (Table5). For example, leaks in city water mains and salt-laden street drainage aretwo important types of external sources. The specific location of the leak inthe distribution system would vary depending on the location of the externalsource.
Expansion devices are the most common specific locations of leaks;30% reported that this is a trouble spot. Most of the systems withcondensate return indicated that the condensate pipe is their biggest leakproblem. Other trouble spots, in descending order of importance, areflanges, welds, valves, steam traps, rollers, and tees.
Eight steam companies indicated that they have condensate return. Ofthese systems, 44% indicated that the condensate pipe is their biggest leakproblem.
4.2.1. Leak Detection Practices
In this report a distinction is made between "detection" (determiningthat a leak exists) and "location" (establishing the location of the leak).
Almost 75% of the respondents indicated that their primary means ofdetecting leaks is a report of visible steam from a manhole or customerinstallation (Table 6). Infrared is used by 11%, while 9% monitor makeupwater requirements to detect leaks. In-line electrical leak detection systemswere installed in five systems, but only three are being used. The othershave been abandoned due to extensive problems with false alarms and otherdeficiencies.
Several systems with condensate returns will typically replace anentire section of condensate line rather than attempt to locate the leak,because of general deterioration of the line.
Three-quarters of the respondents have found one or more methodseffective to some extent in locating leaks (Table 7). Generally, once a leak isdetected, its location is isolated between two manholes on the basis ofvisible steam. Because certain types of system components are weak spots(Table 4), as-built drawings are used to narrow down the possible location.Simply feeling the surface of the pavement for hot spots is used by 34% ofthe systems. Some type of acoustic technology is used by 23%, while 16%use infrared for locating leaks.
21
Table 5. Location of Leaks
Primary location of leaksa
Name of system ED Ex Tr W V F R CP T
Alabama Power CompanyBaltimore ThermalBoston ThermalCentral Heat Distribution (Vancouver)Cleveland ThermalCogeneration Management CompanyConcord SteamConsolidated EdisonDayton Power and LightDetroit EdisonDistrict Energy St. PaulEnergy Networks Inc.Energy Systems Co. - OmahaEugene Water and Electric BoardFairbanks Municipal UtilitiesGeorgia Power Co.Harrisburg Steam WorksIndianapolis Power and LightJamestown Board of Public UtilitiesKent County Public WorksLansing Board of Power and LightMid-America Energy ResourcesMinneapolis Energy CenterNashville ThermalNRG ThermalPacific Energy/Central Plants Inc.Pacific Gas and ElectricPACT, Ltd.Philadelphia ThermalPittsburgh ThermalPublic Service Co. of ColoradoRochester District Heating CooperativeSt. Louis ThermalSeattle SteamToronto District Heating Corp.Trenton District EnergyTrigen - TulsaTrgen - London, OntarioTrigen - Kansas CityTrigen - Nassau CountyUnited IlluminatingWillmar Public UtilitiesWisconsin ElectricYoungstown Thermal
Total
S
" "
0
0 0
"
S "
"
"
"
"
0 0
0
" "
"
"
" 0 .
0
0
0 0 0
0
9
0
"
"
" "
"
"
"
"
"
"
"
"0
0
0
" "
" a
13 15 2 6 4 5 2 8 1
% of respondents 30 34 5 14 9 11 5 18 2
aED = Expansion devices; Ex = Leaks due to external causes; TR = Traps; W = Welds: V = Valves;F = Flanges; R = Rollers; CP = Condensate pipe; T = Service Tee.
22
Table 6. Leak Detection Methods
Methods used for detecting leaks
Visible Infra- Makeup Wire in DepthName of system steam red water conduit of pipe
Alabama Power CompanyBaltimore ThermalBoston ThermalCentral Heat Distribution (Vancouver)Cleveland ThermalCogeneration Management CompanyConcord SteamConsolidated EdisonDayton Power and LightDetroit EdisonDistrict Energy St. PaulEnergy Networks Inc.Energy Systems Co. - OmahaEugene Water and Electric BoardFairbanks Municipal UtilitiesGeorgia Power Co.Harrisburg Steam WorksIndianapolis Power and LightJamestown Board of Public UtilitiesKent County Public WorksLansing Board of Power and LightMid-America Energy ResourcesMinneapolis Energy CenterNashville ThermalNRG ThermalPacific Energy/Central Plants Inc.Pacific Gas and ElectricPACT, Ltd.Philadelphia ThermalPittsburgh ThermalPublic Service Co. of ColoradoRochester District Heating CooperativeSt. Louis ThermalSeattle SteamToronto District Heating Corp.Trenton District EnergyTrigen - TulsaTrigen - London, OntarioTrigen - Kansas CityTrigen - Nassau CountyUnited IlluminatingWillmar Public UtilitiesWisconsin ElectricYoungstown Thermal
Total
% of respondents
0 3-4I
"
"
"
"
"
"
I
I
"
"
"
"
"
"
"
"
0
e
"
S
"
"
"
"
"
"
"
"
"
"
"
"
"
0
32 5 4
73 11 9
10
0
3-98-102-42-8
2-154-6
3-102-10
"
0
8
"
"
2-90
0
4-10
5-183-10
3
7
23
Table 7. Leak Location Methods
Methodstried
withoutMethods found useful a success
Name of system FS A IR Other A IRAlabama Power CompanyBaltimore ThermalBoston ThermalCentral Heat Distribution (Vancouver)Cleveland ThermalCogeneration Management CompanyConcord SteamConsolidated EdisonDayton Power and LightDetroit EdisonDistrict Energy St. PaulEnergy Networks Inc.Energy Systems Co. - OmahaEugene Water and Electric BoardFairbanks Municipal UtilitiesGeorgia Power Co.Harrisburg Steam WorksIndianapolis Power and LightJamestown Board of Public UtilitiesKent County Public WorksLansing Board of Power and LightMid-America Energy ResourcesMinneapolis Energy CenterNashville ThermalNRG ThermalPacific Energy/Central Plants Inc.Pacific Gas and ElectricPACT, Ltd.Philadelphia ThermalPittsburgh ThermalPublic Service Co. of ColoradoRochester District Heating CooperativeSt. Louis ThermalSeattle SteamToronto District Heating Corp.Trenton District EnergyTrigen - TulsaTrigen - London, Ontariob' rigen - Kansas CityTrigen - Nassau CountyUnited IlluminatingWillmar Public UtilitiesWisconsin ElectricYoungstown Thermal
Total% of respondents
0 "
0
"
"
"
I "
0
"
"
"
"
"
"
Leaks not a problem
Leak obvious in tunnel
" Dry spot on rainy day
Leaks not a problem
Use elec. probe if needed0 0
0
In-line elec. system0
S
"
Hand-held thermal meterLeaks not a problem
" Leaks obvious in tunnelsEscape of vapor or waterEscape of vapor or water
0
"
"
0
Leaks not a problem
Drill thru roof of conduit
"
"
"
0
0
"
1534
"
1023
" Leaks not a problem
" Replacing cond. lineDry spot on rainy dayHeath good on HP, not on LPLeaks not a problem
Leaks not a problemLeaks not a problem
716
"
"
0
"
"
aFS = Feel street or vault surface; A = Acoustic; IR = Infrared.bSystem is very old, and operator indicated that no money would be expended on leak repair. Operatorhopes to expand system significantly, at which time in-line leak detection system will be installed.
"
"
8 6iR 14
24
The following is a summary of the experiences of utilities that haveused "acoustic" technologies successfully (in several cases, the devicesactually measure vibration).
" Baltimore Thermal: Heath system, bought four years ago for about$1,000. A receptor, of 3-4 in. diameter, is placed on pavementand moved 3-4 in. at a time. Have a staff person who uses thedevice effectively. Describes accuracy as within 4-5 ft. However,the company is interested in the ANL technology in order tofurther improve effectiveness.
" Cleveland Thermal: Heath system; price about $2000. Staffperson required time to develop a "good ear." Sandy soils in area;system doesn't work with clay soils. Must use between 2:00-5:00a.m., when background noise is minimal.
" Concord Steam: Use city water department's acoustic device, aHeath Aquascope. An acoustic sensor is placed directly on thepavement or in contact with a valve. Where only soil is above thepipe, a bar must be driven down to contact the pipe to obtain agood signal.
* Consolidated Edison: Sometimes uses bar-hole method, wherebar is driven down to contact the conduit. However, this is notalways possible due to obstruction by other utilities (probably30% of system). Bar-holing is also a safety concern.
" Detroit Edison: Drills hole in pavement and inserts sonic probeto contact the conduit; repeats this every foot or so in area inwhere the leak is suspected. Describes accuracy as "hit or miss."Company is interested in the ANL technology.
" Harrisburg Steam Works: Use the "STS Water Leak PinpointingInstrument" made by Paul Michael & Associates, Inc. (814-238-8533). Although Dr. Michael was reluctant to share specifics onthis vibration-measuring device, including the frequencies atwhich it operates, he did provide the information s"own inAppendix C. Dr. Michael sells his device mostly to water utilities,but Harrisburg bought one three years ago, and now several othersteam systems have bought the instrument or plan to do so.
25
Harrisburg indicated that it works well but needs a quietbackground, so it is used the night. Sets on a steel tripod on the
pavement. Dr. Michael prices the device at $3200.
" Pacific Gas and Electric: Can't remember name of maker of thedevice, but thinks it might be Heath. Works well except whenbackground noise is significant.
" Seattle Steam: Bought a device from Dr. Michael (see Harrisburgnotes) for $2600 three months ago. Works very well on directburied pipe, but is tricky with conduit.
" Trigen-Kansas City: Uses Heath Aquascope on high-pressurelines, but it does not work on low-pressure lines. Apparently,sensitivity is too low to detect leaks in the 15-psi low-pressurelines.
" Youngstown Thermal: Borrows Cleveland Thermal's acousticdevice. Works well, but requires practice to use effectively.However, the company is interested in the ANL technology inorder to further improve effectiveness.
Of thesc 10 utilities currently using acoustic technologies with somesuccess, five are interested in the ANL technology because they feel that thecurrent methods are not as effective as is desirable..
Acoustic leak location technology has been tried without success by18% of respondents. Among the potential reasons why some utilities wereable to successfully use acoustic devices while others were unsuccessful arethese: (a) technology used, (b) soil type, (c) staff experience/expertise, and(d) pipe depth. The influence of these factors on the eight utilities thatunsuccessfully tried acoustic devices was not always clear. Generally, if theequipment is no longer used the utility was not able to describe the devicein detail. However, the following notes were obtained on these experiences.
" Alabama Power: "Hand-held sonic tester."
" Boston Thermal: Apparently tried Cleveland Thermal's Heathsystem. They noted that, in contrast to the Cleveland Thermal
26
area, where the technology is used successfully, the soils inBoston are not sandy. Pipe depth is about 10 ft.
" Eugene Water and Electric Board: Unsuccessfully tried"Geophones" used by city water department, described as astethoscope placed on the pavement. Pipe is 2-15 ft. deep.
" Indianapolis Power and Light: Tried Heath technology withoutsuccess 3-4 years ago. Pipe depth varies significantly, from 2 to10 ft.
" Kent County Public Works: Tried water department acousticdevice.
* St. Louis Thermal: Borrowed and used Cleveland Thermal'sequipment, without success. Also tried a leak locationcontractor.
" Wisconsin Electric: Bought an acoustic device (no detailsavailable) about 10 years ago, but was unsuccessful with it.Needed to bar-hole down due to depth of pipe, which rangesfrom 5 to 18 ft.
While seven systems have successfully used infrared technology, six othershave tried this method but found it not effective. Pipe depth may also be asignificant factor in these differences.
4.2.2 Interest in ANL Acoustic Technology
Overall, 41% of the respondents indicated interest in using the ANLacoustic technology, while 59% indicated no interest (Table 8). Utilitiesthat were not interested were asked to explain why; some utilities gavemore than one reason. Responses are summarized below.
" Leaks are not a significant problem: 58%
" Current methods work well: 43%
" Don't want to consider using hot tap: 15%
27
Table 8. General Interest in ANL Technology
Interested in If not, why not?using ANL
technology? Leaks Current Don'tnot a method want
Name of system Yes No problem works hot tap Other
Alabama Power Company "Baltimore Thermal "Boston Thermal "Central Heat Distribution (Vancouver) " "Cleveland Thermal "Cogeneration Management Company "Concord Steam "Consolidated Edison "Dayton Power and Light " "Detroit Edison "District Energy St. Paul "Energy Networks Inc. "Energy Systems Co. - Omaha "Eugene Water and Electric Board " " "Fairbanks Municipal Utilities "Georgia Power Co. "Harrisburg Steam Works "Indianapolis Power and Light "Jamestown Board of Public Utilities " "Kent County Public Works "Lansing Board of Power and Light "Mid-America Energy Resources " "Minneapolis Energy Center "Nashville Thermal "NRG Thermal "Pacific Energy/Central Plants Inc. "Pacific Gas and Electric "PACT, Ltd. "Philadelphia Thermal " "Pittsburgh Thermal "Public Service Co. of Colorado "Rochester District Heating Cooperative " "St. Louis Thermal "Seattle Steam "Toronto District Heating Corp. " "Trenton District Energy "Trigen - Tulsa""Trigen - London, Ontario "Trigen - Kansas City "Trigen - Nassau County " "United Illuminating "Willmar Public Utilities "Wisconsin Electric 0
Youngstown Thermal "
Total 18 26 15 11 4 2
% of respondents 41 59 58 42 15 8% of respondents 41 59 58 42 15 8
28
Although only four respondents who are not interested in the ANLtechnology noted the hot tap as the reason, reservations about hot taps arepervasive and very significant. Concerns about hot taps focus on safety, cost,and introduction of additional potential leak sites.
Listed below are notes on each utility that expressed interest in theANL technology, including their thoughts on hot taps:
" Baltimore Thermal's leak problems are in low-pressure (20-35psi) lines. Key concern is minimizing labor costs.
" Boston Thermal has isolation valves at each manhole, and wouldshut off a section of line to weld in the tap rather than install ahot tap. On average, the system loses about four bellows everyyear and develops several other leaks.
" Consolidated Edison is concerned about hot taps from all threestandpoints noted above. The company bought hot-tapequipment 10 years ago, and has used it, generally for 3-6 in.taps. The equipment is too large to fit into a manhole. Based onexperience, a hot tap costs about $4000 ($3000 for theexcavation plus $1000 for the tap, assuming two men for one dayat $30/hr).
" Detroit Edison stated that cost effective, quick hot-tap servicefrom a contractor would be essential. The company does notallow its staff to do hot taps. About 40 leaks are repairedannually, at a cost of $10,000-15,000 per excavation. Annualbudget for leak work is about $1 million.
" Energy Networks Inc. noted that although leaks are not aparticular problem, some of its older steam pipe is almost 30years old; the company is interested in the ANL technology if itproves to be cost-effective.
" Indianapolis Power and Light noted that its leak problems arealmost all in the low-pressure line (10-15 psi), and that hot tapsin a low-pressure line are not a problem. (Of the 11 systemsproviding both high-and low-pressure service, 5 indicated thatthe low-pressure system is where their leak problems are. The
29
company spends about $1.25 million annually on leak detectionand repair.
" Kent County expressed reservations about hot taps. Quickrestoration of service is key.
" Lansing Board of Power and Light is concerned about corrosionpotential at hot-tap sites. Leaks do not receive a high priority atpresent.
" Minneapolis Energy Center felt that a hot tap could be done in amanhole if the leak is small enough.
" NRG Thermal's leak problems are unusual: they generally occurin a 150-psi condensate line. Because a portion of the line islocated along railroad tracks, shoring requirements makeexcavation very expensive (perhaps $25,000 per hole). Hot tapsof less than 1/2 in. do not appear to be a problem and could bedone in vaults, but cost is estimated at about $1000 per tap.
" Pacific Energy Co./Central Plants Inc. is interested in the ANLtechnology, but needs are unusual because most of its systemsare chilled water or high-temperature hot water; only a smallamount of steam service is provided.
" PACT, Ltd. is fairly successful in locating leaks, but is interestedin improvement. The company is concerned about hot taps,particularly in conined spaces.
" Pittsburgh Thermal's primary concern is leaks in its condensatelines.
" St. Louis Thermal would not buy the ANL acoustic equipment butwould be interested in contracting with a company that ownsthe equipment.
30
* Toronto District Heating Corp. has problems in locating leaks inits low-pressure (15 psi) line. As a result, the company isinterested in the ANL technology if the hot taps can be done inmanholes, so excavation would not be necessary.
" Trenton District Energy and Trigen-Tulsa are interested for thelong term, although leaks are currently not a major problem foreither company.
Most of the companies that expressed interest are looking for a mobilesystem to be implemented as needed (Table 9). Only two expressed interestin a permanent leak detection and location system.
All of the companies expressing overall interest in the ANL technologywould consider hosting a field test, depending on specifics (particularlycost).
4.2.3 European Experience
The following descriptions of European leak location practices arebased on discussions with these individuals:
" Dr. Hans Mortensen, President of the Metropolitan CopenhagenHeating Transmission Co. In addition to managing theCopenhagen system, which has 30 miles of twin pipe, Dr.Mortensen is very active in the International Energy Agency ondistrict heating matters.
" Sture Andersson, who has served as Production Manager of theMalm6 Energy Authority in Malmo, Sweden, and as Chairman ofDistrict Heating Technology at Varmeforsk, the SwedishThermal Energy Research Institute. He is currently responsiblefor Research and Development at Malm6 Energy, and isProfessor in district heating at the Institute of Technology inLund.
" Eric Peterson of A/S Bjeld & Lauridsen, a Danish company thatprovides infrared leak detection and location servicesthroughout Europe.
31
Table 9. Specific Interest in ANL Technology
Interested
Types of system in fieldoftnterst test?
Permanent MobileName of system system system Yes No
Alabama Power CompanyBaltimore Thermal " " "Boston Thermal "Central Heat Distribution (Vancouver)Cleveland ThermalCogeneration Management CompanyConcord SteamConsolidated Edison " "Dayton Power and LightDetroit Edison " "District Energy St. PaulEnergy Networks Inc. "Energy Systems Co. - OmahaEugene Water and Electric BoardFairbanks Municipal UtilitiesGeorgia Power Co.Harrisburg Steam WorksIndianapolis Power and Light "Jamestown Board of Public UtilitiesKent County Public Works " "Lansing Board of Power and Light " "Mid-America Energy ResourcesMinneapolis Energy Center "Nashville ThermalNRG Thermal " "Pacific Energy/Central Fiants Inc. " "Pacific Gas and ElectricPACT, Ltd. "0"Philadelphia ThermalPittsburgh Thermal " "Public Service Co. of ColoradoRochester District Heating CooperativeSt. Louis Thermal " "Seattle SteamToronto District Heating Corp.Trenton District Energy "Trigen - Tulsa "Trigen - London, OntarioTrigen - Kansas City "Trigen - Nassau CountyUnited IlluminatingWillmar Public UtilitiesWisconsin ElectricYoungstown Thermal
Total 2 10 18% of respondents 5 23 41
32
Electric Alarm Systems: In-line electric alarm systems generally were
installed during construction of European district heating systems afterapproximately 1975. Initially, many of these systems had significantproblems with false alarms and other malfunctions, due to poor qualitycontrol during the manufacture of prefabricated pipe sections, as well as tobad connections between pipe sections in the field. (Notably, these sametypes of problems have been visible in North American installations. Thishas resulted in considerable efforts to "debug" these systems and, in twocases, abandonment of the alarm system.) These problems have apparentlybeen solved in Europe through attention to proper workmanship, both inthe factory and in the field.
Infrared Imaging: The electric alarm systems are sometimesaugmented with infrared techniques; in older systems, infrared is theprimary leak detection and location method. Infrared images can be takenwith a camera mounted on the roof of a car or on an airplane flying at aaltitude of no more than 300 m.
Infrared imaging is best done at night when it is not raining and whenthere is no snow on the ground. Fog is also problematic. The best imagesare generally obtained in spring or fall.
The use of infrared is much more widespread in Europe than in NorthAmerica, at least in part because hot water, rather than steam, is theprimary medium of heat transmission in European DH systems. The highertemperatures in steam piping apparently result in more blurring of theinfrared image, thereby reducing its value in pinpointing the location ofleaks.
Another factor is pipe depth. Bjeld & Lauridsen has stated that theinfrared technology is useful in examining pipes no more than 2 m deep.Danish district heating pipes, for example, are normally about 1 m deep.
At the Studsvik Research Institute in Sweden, thermography is now
being further developed so that it can not only detect and locate leaks butalso quantify the extent of heat loss.
Acoustic Technologies: Almost two-thirds of the district heatingpiping in what was formerly West Germany were installed without in-line
33
electric alarm systems. To address the needs of these systems, work hasbeen done to develop an acoustic leak location technology called "Lokal."This technique is similar to that being pursued by ANL, i.e., correlationanalysis of acoustic signals from sensors placed on each side of thesuspected leak area. However, the sensors are placed on the pipe ratherthan in-stream, as has become necessary to provide accuracy in location ofleaks in steam pipes. The German work is directed toward hot water pipes.The development of "Lokal" was undertaken under the auspices of the IEAduring 1984-87, and an IEA report was published.
Dyes: One more technique being developed for leak detection is theintroduction of a dye into DH water. Although the purposes of this technique(detecting leaks into building domestic hot water or into the buildingsubstation) are different than that of the leak detection technology beingdeveloped by ANL, it is described here as a matter of interest.
In Sweden, only a single-wall heat exchanger separates district hotwater from the domestic hot water supply for the buildings served. As aresult, considerable attention is paid to preventing leaks from the districtsystem into the domestic hot water supply. To address this issue, testswere conducted with a dye called pyranine. The results were encouraging,and even small leaks could be detected.
4.i Conclusions from Survey
1. The extent to which leak detection is important varies considerablyfrom utility to utility.
" At least three of the larger utilities spend $1 million or more eachyear locating and repairing leaks.
" One-half of the respondents do not consider leaks to be a problemand/or are satisfied with current leak location methods.
- More than one-third (34%) of the respondents do not considerleaks a significant problem.
- One quarter of the respondents are satisfied with their currentmethods for locating leaks. Within this group, 9% also indicatedthat leaks are not a problem.
34
2. The most common leak location method is decidedly "low-tech":feeling the pavement to see where it is hottest and/or zeroing in on specifictrouble-spot components using as-built drawings.
3. Almost one-quarter (23%) of the respondents have found an acoustictechnology useful to some extent in leak location, while 18% have tried anacoustic technology without success.
" A particular acoustic technology that has been used with goodsuccess by one utility may be totally ineffective for another.
" The effectiveness of various acoustic or vibration-sensing devicesappears to depend on a variety of factors, including the particularacoustic device used, staff expertise/experience, soil type, and pipedepth.
" Existing acoustic technologies are relatively inexpensive (severalthousands of dollars).
* One-half of the respondents that found an existing acoustic technologyuseful also stated that they are interested in the ANL technologybecause their current methods are not as effective as desirable.
4. There is significant interest in the ANL technology, particularly amongthe larger steam utilities.
" More than 40% of the utilities surveyed are interested in using theacoustic leak detection and location technology being developed byANL.
" The utilities interested in the ANL technology represent 76% of thetotal thermal energy sales by the surveyed utilities for which sales datawere available.
" Of the utilities that expressed an interest in the ANL technology, 28%do not feel that leak detection is a high-priority problem.
35
" Of the utilities expressing no interest in the ANL technology, thefollowing reasons were cited: leaks are not a problem (58%); current
methods work well (42%); don't want to do hot taps (15%).
5. The market for the ANL technology is likely to be limited to arelatively few large steam systems.
" The likely capital cost of the ANL technology ($40,000-50,000,according to ANL) is very high relative to other leak locationtechnologies.
" However, this cost could be quickly recouped (due to the high cost ofexcavation) by utilities with a significant number of leaks and for whomthe existing acoustic or other technologies do not work.
6. Most utilities are reluctant to do hot taps, and this presents asignificant potential barrier to the use of the ANL technology.
" Concern about hot taps appears to be based on prior experience withlarge (several-inch) hot taps.
" Concerns about hot taps include safety, cost, and introduction ofadditional potential leak sites.
" To minimize overall operational costs of the ANL technology, it isimportant that the hot tap be performed in a manhole.
" The safety and cost problems with the size of tap likely required withthe ANL technology (1/2 in. or less) should be considerably reducedcompared to larger hot taps; this must be confirmed, quantified, anddemonstrated.
5 Acoustic Leak Location by Cross-Correlation Analysis
A few examples of leak location by cross-correlation analysis ofacoustic signals generated by a leak are presented ,o illustrate the potentialfor success and also the problems associated wigr this technology.
3 6
5.1 Leak Location with a Commercially Available Correlator at theANL Steam Leak Facility
Using leaks generated in the ANL steam leak facility,1 we evaluated aMetravib leak locator. In the Metravib system, accelerometers transmitsignals to a central processing unit via radio waves. The Metravib unit hasfixed-frequency windows; those evaluated were 400-1450, 400-2200, and400-3000 Hz. Correlation peaks from the Metravib unit were observed withsensors located 6.4 and 12.8 m from the leak. Steam pressures in the rangeof 40-70 psi were used. The window of 400-3000 Hz was optimal for theMetravib system. With the two lower-frequency windows, no correlationpeak associated with the leak was observed. One observed peak was due tonoise in the system, which is easily filtered by using a frequency windowwhose lower limitis higher. While such filtering is not possible with theMetravib system, it is with the ANL instrumentation. Another correlationpeak showed a 9-ms differential, indicating a leak-to-sensor spacing of about10 m, if the empirically determined velocity of sound of 1100 m/s is used.This result is consistent with the actual 12.8-m sensor-to-leak spacing, butthe error is large (about 30%).
The commercially available Metravib system is comparable in somerespects to the ANL system but has limitations in several areas when used tolocate steam leaks. The low- and high-frequency ranges should be moreflexible to allow use of frequency windows such as 1-2, 2-4, and 3-6 kHz.The current Metravib system does not filter noise that the ANL system can;moreover, it requires a higher sampling rate and more sampling points.The Metravib system should also present the frequency spectrum for bettercharacterization of noise sources, and it should have sensors that cantolerate steam pipe temperatures to allow direct contact with hot pipes.
5.2 Leak Location with a Commercially Available Correlatorunder Field Conditions
On September 20, 1991, personnel from Earl Ruble and Associates(Duluth, Minnesota) used a cross-correlation technique in attempting tolocate three leaks in a Northern States Power (NPS) district heating system.These leaks were in pipes filled with hot water (condensate return line,240*F, 150-200 psi). In the technique used, an acoustic sensor (withfrequency response ranging from 100 Hz-2 kHz) was placed on one end of
37
each of two waveguides. The other ends of the waveguides are put incontact with the pipe in two different manholes on either side of thesuspected leak. Cables carried the electrical signals to the instrumentationfor the location analysis. The first leak could be heard at two manholes 391ft apart. However, no correlation peaks were evident that could be used toaccurately locate the leak.
In past field studies, Ruble and Associates have discovered thatpipelines in air (not buried), such as those suspended on wall brackets in abelow-ground room, tend to "ring." They believe that this is because asound wave traveling along the water causes the pipe to vibrate in anextremely minute manner, creating sound waves that are in the samefrequency ranges as true leaks. In this case, the leak sound was extremelystrong and it could have induced the pipe vibration that is described asringing. This ringing could overwhelm the leak sound and prevent asuccessful cross-correlation analysis. Without the damping effect ofsurrounding soil or sand, ringing can occur in varying degrees, dependingon all the factors at a particular location. In the case of the NSP condensatereturn line, the pipe is encased in a very-low-density insulating materialdesigned to prevent heat loss but not to support a pipe securely. In such asituation, there is no known method of correlating a leak if the conditionsare adequate to cause the ringing.
The second field trial was at a location said to be between transducerlocations 600 ft apart. The second pipeline is constructed just like the onedescribed above. A weak leak sound was detected, but the correlation wasvirtually ideal. The signal-to-noise ratio was good and the leak location wasspecific. However it placed the leak at the "east" transducer. This means theleak was at that point or at a location farther away along the pipeline. Fromprevious experience with this situation, the leak was either at thetransducer location or was out of span (not between sensors) somewherefarther east of the "east" transducer location because there is no branch offthe condensate line. The test equipment was rearranged so that thepresumed leak would lie between the old east transducer and the newtransducer farther east. Again, an excellent leak pattern was obtained onthe monitor. In this case, the leak was indicated to be 19 ft west of what isnow referred to as the new east transducer location. This was perplexingbecause that is where an excavation had been made a week earlier to repaira leak. Excavation later revealed that the source of the noise was indeed a
38
leak from a temporary clamp about 19 ft from the transducer location, aspredicted. The leak rate was very small, also as predicted.
A question that must be answered is why it was possible to obtain agood correlator pattern on the monitor screen in the second case and not inthe first. At present, we believe that the insulation in contact with the pipeprovides enough damping to reduce the ringing and permit the leak soundto predominate in the second case (smaller leak). It is possible that thehigh pressures are important factors here as well.
At the third location, a strong leak was detected. However, pumpsfrom a paper mill about 1200 ft away caused interfering sounds and acorrelation analysis was not possible.
5.3 Leak Location with a Research-Quality Correlator underLaboratory and Field Conditions
Laboratory tests were carried out at ANL with artificial leaks underconditions that simulate the temperature and pressure of a steamdistribution system (180 psi, 350 F). Laboratory-quality instrumentation(Spectral Dynamics Signal Analyzer SD375, Khrone-Hite filters. andTektronix AM502 amplifiers) were employed. Laboratory testing wassuccessful when sensors were placed directly on the pipe outer wall. Fieldtests with this system indicated that, in many situations, steam leaks inunderground piping system can be located by acoustic techniques. However,application of the tested technology to underground piping is subject tolimitations, chief of which is the presence of bellows that severely attenuatethe acoustic wave generated by the leak. Where two acoustic sensors can beplaced on bare pipe on either side of a leak, with no bellows intervening, itis possible to detect and locate a leak by cross-correlation analysis. Wheremanholes are separated 200 ft or more, it should be possible to detectsteam leaks with sensors placed on the pipe outer wall if the leak is large(i.e., significant vapor is visible at one or both manholes).
5.4 Leak Location with an In-Stream Sensor
Transducers or transducer/waveguide systems placed directly on the
steam pipe outer wall may not be effective enough to locate leaks in longruns of DH piping or in runs with bellows between sensors. One possibility
39
for circumventing the general problem of steam leak detection withexternally mounted sensors is to insert an acoustic transducer inside thepipe to detect steam-propagated sound waves directly. The main purpose ofthe program being carried out at ANL in collaboration with NRG Thermal
and Consolidated Edison is to develop an in-stream sensor for steam leaklocation.
We have carried out a brief evaluation of in-stream monitoring using acapacitance microphone to illustrate the potential for improvements inlocation capability. Cross-correlation analysis of signals from a gas leak inthe ANL piping system suggests that in-stream monitors are more effectivethan sensors mounted on the pipe outer surface. The use of commerciallyavailable capacitance microphones or miniature hydrophones (e.g., bruel andKjaer model 8103) may not be viable for detection of steam-propagatedsound because of the elevated temperature of the steam. Special high-temperature microphones (e.g., Endevco models 2510 or 8521-5M 1) aredesigned for high-intensity applications (e.g., jet engine noise) and may notbe sensitive enough for detection and location of steam leaks. The mostpromising sensor is one made of a piezoelectric material fixed in a tubeabout 1/2 in. in diameter and able to tolerate the elevated temperatures andpressures of a steam system. Such high-temperature microphones can beinserted without disturbing service, by means of a hot tap.
6 Conclusions
Several leak detection techniques are currently available for districtheating and cooling systems. Application and effectiveness of eachtechnique depend on the design and installation method of the DHC piping,location of the leak (in the jacket or the carrier pipe), system operatingparameters, and knowledge of system layout and components. The mostcommon systems used today are classified according to their principle ofoperation as follows: acoustic emission, infrared spectroscopy, tracer gas,and electrical.
While all of these techniques have been tried in one form or another,only acoustic leak detection has the potential for being the most effective forlocating leaks. However, sensors placed directly on the pipe outer wall maynot be effective enough for acoustical location of steam leaks in long runs ofDHC piping. One way to circumvent the general problem of steam leak
40
detection in buried pipe is to insert an acoustic transducer inside the pipeto detect steam-propagated sound waves directly.
A survey was undertaken as part of a joint program between the U.SDepartment of Energy and utilities involved with district heating andcooling. The purpose of the survey is to identify and characterize currentpractices for detecting and locating leaks in district heating systems;specifically steam systems. This information reflects district heatingindustry conditions, needs, and requirements and will assist ANL in thedevelopment of acoustic leak detection technology
Acknowledgments
The authors wish to thank M. Spurr for the survey data and W.Lawrence, R. Popper, and R. Carlson for their contributions to this project.
41
References
1. D. S. Kupperman and D. E. Karvelas, Acoustic Leak Detection forDistrict Heating Systems, Argonne National Laboratory ReportANL-87-60 (Feb. 1988).
2. K. E. Cooper, C. Marsh, and E. G. Segan, Evaluation of Techniques forLocating Leaks in Underground Heat Distribution Systems, U.S. ArmyCorps of Engineers, Construction Engineering Research LaboratoryTechnical Report M-86/16 (Aug. 1986).
3. D. S. Kupperman, T. N. Claytor, T. Mathieson, and D. Prine, LeakDetection Technology for Reactor Primary Systems, Nucl. Safety,28:191 (April-June 1987).
4. J. Reason, Acoustic Leak Detection Provides Early Warning of PipingFailure, Power, 63 (Sept. 1987).
5. J. E. Coulter, T. P. Sherlock, and D. M. Stevens, Acoustic EmissionMonitoring of Cracks in Fossil Fuel Boilers, Electric Power ResearchInstitute Report EPRI CS-5264 (July 1987).
6. J. G. Dimmick and J. M. Cobb, Ultrasonic Detection Cuts ValveMaintenance Costs, Power Eng. 35 (Aug. 1986).
7. D. 0. Harris, R. G. Brown, D. Dedhis, and D. E. Leaver, AcousticEmission Leak Detection and Location Systems Technology Review,Electric Power Research Institute Report EPRI NP-80-7-LD (Dec.1980).
8. H. V. Fuchs, W. Frommhold, R. Poggemann, R. and P. Zenker,Acoustic Leak Location on District Heating Pipes, HLH, Heizung,Luftung, Klimatechnik, Haustechnik, 42:1; Fraunhofer-Institut furBauphysik, Stuttgart, and Energieversorgung Oberhausen AG, WestGermany.
9. H. Schwarze, Computer-aided Measuring System for AutomaticMonitoring of Pipe Networks and Leak Detection, TechnischesMessen, 55(7-8): 279-285; Fachhochschule Bielfeld, Bielfeld, WestGermany (1988).
42
10. H. J. Micheel, Leakage Monitoring in Synthetic Jacket Pipes forDistrict Heating Supply, Fernwaerme International, 16(6):380-385, Salzgitter Elektronik GmbH, Kiel, West Germany(Nov-Dec 1987).
11. D. B. Chang, B. M. Pierce and I. Shih, Environmental MonitoringTechnologies, SAE Technical Paper Series 910190, InternationalCongress and Exposition, Detroit, Feb. 25-March 1, 1991.
12. H. Turtiainen, Leak Location in District Heating Networks UsingAcoustical Correlation Techniques, Valtion TeknillinenTutkimuskeskus, Espoo, Finland (1982).
13. H. Gransell and J. Ljungquist, In Situ Control of District HeatingNetworks, Annual Conference of the Int'l District Heating Assoc.,(1985).
14. A. Jette, M. Norman, S. Michael, J. C. Murphy, and J. G. Parker,Active Acoustic Detection of Leaks in Underground Natural GasDistribution Lines, Materials Evaluation, 35(10): 90-96, 99(Oct. 1977).
15. A. C. Eapen, R. L. Amera, S. M. Agashe, Pipeline Leak Location UsingRadiotracer Technique, Bhabha Atomic Research Centre, IsotopeDiv.. Bombay, India (1983).
43
Appendix A:
Survey Form and Introductory Remarks forAcoustic Leak Detection and Location
44
45
Introduction to Survey
Argonne National Laboratory, under contract to the U.S. Department ofEnergy and several district heating utilities, is developing a system fordetecting and locating district steam piping leaks using acoustic technology.
The objective of the project is to develop a highly accurate acousticleak detection and location system so that excavation for repairs can beminimized. Based on previous work, it appears that for steam districtheating an in-stream sensor, probably using a hot tap, will be required toachieve the desired accuracy (within several meters).
The system would involve the insertion of two transducers into the hottaps, without disrupting steam service. Transducers could be attachedpermanently, to be periodically monitored, or a pair of transducers, as partof a mobile unit, could be placed as needed at sites of interest. Signals fromthe transducers would be transmitted by wire or radio waves and would beprocessed by mobile computer equipment.
Argonne is now performing research necessary for development of afield-implementable prototype system. On behalf of Argonne, I'd like to talkwith you about leak detection and location practices and experiences in yoursystem so that the prototype system is developed with a full understandingof district heating industry needs and requirements.
46
LEAK DETECTION SURVEY
Name of System
Contact Name
Phone
&a. Distribution yStem
1. Year oldest pipe installed
3. Type of pipe installation
Box conduitSolid pour conduitTunnelPrefab conduitDirect BurialOther
5. Intervals between expansion devices
6. Condensate return? yes
7. Intervals between manholes
8. Temperature and pressure
2. Miles of pipe
4. Expansion devices
Slip jointsBellowsBall jointExp. loopOther
feet
no
feet
rFF
psi (HP steam)psi (LP steam)psi (hot water)
B. Current Leak Detection
1. What types/locations of leaks are your biggest problem?
ValvesFlanges Expansion devicesOther
2. How are leaks detected now?
Rollers WeldsExternal corrosion
3. How are leaks located?
-1
47
4. What is the accuracy of your location methods?
C U a of Acoustic System
1. Would you be interested in using an acoustic system asdescribed earlier? yes _ no
2. If not, why not?
3. What would increase this system's usefulness to you?
4. Are you interested in:
a. Ongoing system for monitoring, detection andlocation
b. A system for use as necessary to locate leaksdetected through other means
5. Would you be interested in field testing a prototypesystem? yes no
48
49
Appendix B:
Notes From Survey
50
Name of System
Contact Name
Phone
51
LEAI DETECTION SURVEY
~/e t'^A5..b e,%,.0 1/0
arm yw- M --- ewoo
8. Temperature and pressure 3 -37o FFF
/5~a psipsipsi
(HP steam)(LP steam)(hot water)
B. Current Leak Detection
1. What types/locations of leaks are your biggest problem?
Valves Rollers
Welds Flanges
Expansion devices External corrosionOther -73rp_
A. Distribution System
1. Year oldest pipe installed fc6 2. Miles of pipe _
3. Type of pipe installation 4. Expansion'devices
Box conduit _______ Slip jointsSolid pour conduit Bellows n a v-rTunnel Ball jointPrefab conduit .-- ajcot _Exp._loop
Direct Burial Other
Other
3--c' yw.
5. Intervals between expansion devices ___feet
6. Condensate return? yes _______ no
7. Intervals between manholes 'YD feet
52
2. How are leaks detected now?
3. How are leaks located?
V7/ 404A, c74 1 .57 r / /c
4. What is the accuracy of your location methods?
C. Use of Acoustic System
1. Would you be interested in using an aco ic system asdescribed earlier? yes ___no
2. If not, why not?
3. What would increase this system's usefulness to you?
4. Are you interested in:
a. Ongoing system for monitoring, detection and locationb. A system for use as necessary to locate leaks detected
through other means
5. Would you be intereted in field testing a prototype system?
yes no
cs\leaksurv
53
N
pi
A
1
3
LEAX DETECTION SURVEY
are of System 9 dM .,e
contact Name ir/ a S6 'v /Ayr , A_2Jdn A
hone __ /__________
. Distribution System
. Year oldest pipe installed 2. Miles of pipe /.
. Type of pipe installation 4. Expansion devices
Box conduit & ____Slip joints 'Solid pour conduit Bellows ______
Tunnel Ball joint
Prefab conduit Exp. loop -oDirect Burial Other
Other
5. Intervals between expansion devices ^-ago feet
6. Condensate return? yes no
7. Intervals between manholes as ~ feet - ,36-47 /L4CX / 5 7
8. Temperature and pressure 37S F /bo-/r psi (HP steam).7o F ao-3r psi (LP steam)
F psi (hot water)
B. Current Leak Detection
1. What types/locations of leaks are
ValvesWeldsExpansion devicesOther . Svey 7 T
your biggest problem?
RollersFlangesExternal corrosion
~
54
2. How are leaks detected now?
1/;VA 09,, a o(- QL 4,0
3. How are leaks located? 7 - A
4i -ak JY 6, 4o %'-ae4. What is the accuracy of yo~r location methods?
C. Use of Acoustic System
1. Would you be interested P using an acoustic system asdescribed earlier? yes no
2. If not, why not?
3. What would increase this system's usefulness to you?
Aljn1 4G G4w- cc17
4. Are you interested in:
Ongoing system for monitoring, detection and locationA system for use as necessary to locate leaks detectedthrough other means
5. Would you be interested in field testing a prototype -system?
yes no
cms\leaksurv
55
(
LEAK DETECTION SURVEY
lame of System i 9 / Air EAM
Contact Name 2h4 /2i, 4e/
Phone 5-A -- /g'ado
A. Distribution System
1. Year oldest pipe installed /9c 2. Miles of pipe
3. Type of pipe installation 4. Expansion devices
Box conduit ___-__ Slip jointsSolid pour conduit Bellows(T/BloTunnel Ball__on
Prefab conduit alta_ _Exp._loop
Direct Burial OtherOther
-7 -f -rrx er t OU740
5. Intervals between expansion devices _____feet
6. Condensate return? yes no
7. Intervals between manholes '/D feet
8. Temperature and pressure 3d 37o F
__-__ FF
/So psipsipsi
(HP steam)(LP steam)(hot water)
B. Current Leak Detection
1. What types/locations of leaks are your biggest problem?
1. Would you be interested in using an oustic system asdescribed earlier? yes no
2. If not, why not?
3. What would increase this system's usefulness to you?
4. Are you interested in:
a. Ongoing system for monitoring, detection and locationb. A system for use as necessary to locate leaks detected
through other means
5. Would you be interested in field testing a prototype system?
yes no
cms\leaksurv
Ors !moo 4eAv6wp o4e 6vz-, -J JAS4P-
N
C
P
A
1
3
Intervals between expansion devices -ioj feet
Condensate return? yes no
intervals between manholes /O' feet - -2ase .7 - /De
8. Temperature and pressure FFF
B. Current Leak Detection
1. What types/locations of leaks are
ValvesWeldsExpansion devices ~./ /' 3other
j psi (HP steam)psi (LP steam)psi (hot water)
your biggest problem?
Rollers
FlangesExternal corrosion
131
LEAK DETECTION SURVEY
ame of System 7r'- X 4 , 6 k
ontact Name 4 hone -- D ir-- *
hone ______________ &f.
. Distribution System
. Year oldest pipe installed l1O 2. Miles of pipe cP
. Type of pipe installation 4. Expansion devices
Box conduit Slip joints i~Solid pour conduit Bellows /
Tunnel Ball jointPrefab conduit Exp. loop
Direct Burial Other
Other
5.
6.
7.
A 40
Dr.4, Cc vim, Gx.G,
132
2. How are leaks detected now?
3. How are leaks located?
4. whatst4 ur
4. What is the accuracy of your location methods?
C. Use of Acoustic System
1. Would you be interested i sing an acoustic system asdescribed earlier? yes no
2. If not, why not?
3. What would increase this system's usefulness to you?
4. Are you interested in:
a. Ongoing system for monitoring, detection and locationb. A system for use as necessary to locate leaks detected
through other means
5. Would you be interested in field testing a prototype system?
yes no o Ss,, *
cms\leaksurv
T4
133
Distribution for ANL-92/5
Internal:
W. E. Brewer W. P. Lawrence R. W. WeeksH. Drucker C. A. Malefyt (2) ANL Patent Dept.N. Heeg A. C. Raptis ANL Contract FileD. E. Karvelas S. H. Sheen TIS Files (3)D. S. Kupperman (50) C. E. TillR Lanham R. A. Valentin
External:
DOE-OSTI, for distribution per UC-350 (331)ANL Libraries (3)DOE Chicago Operations Office:
ManagerF. Herbaty
Materials and Components Technology Division Review Committee:H. Berger, Industrial Quality, Inc., Gaithersburg, MDM. S. Dresselhaus, Massachusetts Institute of Technology, Cambridge, MAS. J. Green, Electric Power Research Institute, Palo Alto, CAR. A. Greenkorn, Purdue University, West Lafayette, INC.-Y. Li, Cornell University, Ithaca, NYP. G. Shewmon, Ohio State University, ColumbusR. E. Smith, Electric Power Research Institute, NDE Ctr., Charlotte, NC
Elaine K. Allen, Green & Associates, DallasMr. Mark Anderson, NRG Thermal, MinneapolisCarl E. Avers, Catalyst Thermal Energy Corp., Youngstown, OHMark Avers, Baltimore Steam Co., BaltimoreArturo F. Barcena, Medina, NYJeffrey P. Bees, Youngstown Thermal Corp., Youngstown, OHLeif Bergquist, Trigen Energy Corp., New YorkIver Blackberg, Blackberg Assoc., Arlington Heights, ILTimothy Block, Detroit Edison Co., DetroitDavid Bonkovich, Heath Consultants, Inc., Belle Vernon, PAJames R. Brooks, Baltimore Steam Co., BaltimoreRudy Brynolfson, St. Paul, Inc, St. PaulFrederick Callowhill, Exec. Dir., IDHCA, Sanford, NCJohn M. Casey, Univ. of Georgia, AthensWyndham Clarke, U.S. Dept. of Housing & Urban Dev., Washington.Lewis C. Cohen, Philadelphia Thermal Corp., PhiladelphiaFloyd Collins, DOE, WashingtonRobert O. Couch, RPSI, Inc., Brecksville, OHMr. M. Danbo, J.C. Hempel's Handelssus A/S, Copenhagen K, DenmarkGlen H. Fukuda, Fukuda Intl., Lafayette, CA
134
Jack Gleason, WashingtonBill Goodwin, Harrisburg SW, Ltd., Harrisburg, PAGary Gustafson, MEC, MinneapolisJames F. Harley, Intergy, Inc., Brecksville, OHGene Hess, Wisconsin Elec. Power Co., MilwaukeeDavid F. Hobson, IDHCA, WashingtonJay Holmes, USDOE, WashingtonLeslie J. Jardine, Bechtel National, Inc., San FranciscoLoraine Kasprzak, Consolidated Edison Co. of New York, Inc., New YorkJack Kattner, MEC, 1060 IDS Center, Minneapolis, MNP.G. Kemp, GAP Technologies, Menlo Park, 0102, South AfricaBrian Kirk, Consolidated Edison, New YorkY. Kitaura, Sumitomo Chemical America, Inc., New YorkJohn Kuhns, Catalyst Energy Dev. Corp., New YorkWilliam Mariutto, KAFA Intl., Rivera Beach, FLRichard Mayer, PG&E Co. San FranciscoMichael E. McKay, Princeton Univ., PrincetonDr. William Messner, Consolidated Edison R&D, New YorkAnthony C. Mirabella, Energy Networks Inc., Hartford, CTMichael J. Nagel, Univ. of Minnesota Plant, MinneapolisE. W. Ng, Consolidated Edison, New YorkHans Nyman, St. Paul, Inc., St. PaulYousuf H. Al Omar, United Gulf Construction Co. WLL, Safat, KuwaitIshai Oliker, Burns and Roe, Ordell, NJSeth J. Perkinson, III, The Perkinson Co., Charlotte, NCRobert J. Perry, Heath Consultants, Inc., Stoughton, MAEugene Peters, 301 N. Amin Ave., Scranton, PASigrid H. Pilgrim, Intercon Research Associates, Ltd., Evanston, ILChristopher Pioli, Dept. of Utilities-Gas Division, Colorado Springs, CODean Price, Georgetown University, WashingtonW.L. Puckering, W.L. Puckering Consulting, Inc., Vancouver, B.C.Hermine Randall, Univ. of Mass./Amherst, Amherst, MAZeph Regnier, 140 Promenade du Portage Phase IV Lv2, Hull, Quebec KiA OM3Anders Rydaker, District Energy Systems, Roseville, MNPaul J. Sausville, Bulk Storage Section, Div. of Water, AlbanyRoger E. Scholl, URS/John A. Blume & Associates, San FranciscoBeth Schumake, Neotronics North America, Inc., Gainesville, GAMark Spurr, Resource Efficiency, Inc., St. PaulDarrell D. Stalzer, Iowa EL & P Co., Cedar Rapids, IAFred Strnisa, NY State Energy R&D Auth., AlbanyDavid W. Wade, Resource Dev. Assoc., Inc., Atlanta, GAGalen Young, Fisher Research Lab., Los Banos, CA